Downhole well tool with groove

ABSTRACT

A downhole well tool includes a tool body attached to a well string, a sealing packer element partially circumscribing the tool body from a first circumferential end to a second circumferential end, a side groove formed at least partially in the tool body and positioned between the first circumferential end and the second circumferential end of the sealing packer element, and a fluid conduit disposed within the tool body and extending to the side groove. The sealing packer element expands and seals against an inner wall of a wellbore. The side groove forms a channel in an exterior surface of the tool body between the first circumferential end and the second circumferential end of the sealing packer element, and the fluid conduit includes at least one nozzle positioned at the side groove, where the fluid conduit flows a fluid into the channel of the side groove.

TECHNICAL FIELD

This disclosure relates to downhole well tools that seal against a wellbore wall.

BACKGROUND

In the oil and gas industries, some downhole well tools include sealing packers to seal against a wall of a wellbore. In order to run a cable past a set packer from a tool downhole of the packer to uphole of the packer, the cable is spliced and penetrates the tool body of the packer and then runs uphole, for example, for connection to a tophole power source or communications source.

SUMMARY

This disclosure describes a downhole well tool with a side groove.

Some aspects of the disclosure encompass a downhole well tool. The downhole well tool includes a tool body to attach to a well string, a sealing packer element partially circumscribing the tool body from a first circumferential end to a second circumferential end of the sealing packer element, a side groove formed at least partially in the tool body and positioned between the first circumferential end and the second circumferential end of the sealing packer element, and a fluid conduit disposed within the tool body and extending to the side groove. The sealing packer element expands and seals against an inner wall of a wellbore, the side groove forms a channel in an exterior surface of the tool body between the first circumferential end and the second circumferential end of the sealing packer element, and the fluid conduit includes at least one nozzle positioned at the side groove, where the fluid conduit flows a fluid into the channel of the side groove.

This, and other aspects, can include one or more of the following features. The downhole well tool can further include a cable positioned within the channel of the side groove, where the cable extends from a well tool downhole of the tool body, through the channel of the side groove and across the sealing packer element, and to a location uphole of the tool body. The sealing packer element can be an electric submersible pump packer, the cable can be an electric submersible pump cable, and the downhole well tool can connect to an electric submersible pump positioned downhole of the sealing packer element. The cable can include at least one of a power cable, a communications cable, or a hydraulic cable. The downhole well tool can further include a clamp to secure the cable to the well string. The clamp can be a first clamp positioned downhole of the sealing packer element and configured to secure the cable downhole of the sealing packer element, and the downhole well tool can further include a second clamp positioned uphole of the sealing packer element, where the second clamp is configured to secure the cable to the well string uphole of the sealing packer element. The at least one nozzle includes a plurality of nozzles fluidly connected to the fluid conduit, and the plurality of nozzles are distributed along the side groove. The plurality of nozzles can be distributed in a linear pattern along a longitudinal length of the side groove. The plurality of nozzles can be evenly distributed in the linear pattern. The sealing packer element can include a partial ring shape with a split, where the first circumferential end and the second circumferential end define the split. The sealing packer element can be radially expandable and configured to radially expand from a first, radially retracted position to a second, radially expanded position of the sealing packer element. The sealing packer element can include an inflatable packer configured to inflate from the first, radially retracted position to the second, radially expanded position. The sealing packer element can include a swellable packer configured to swell from the first, radially retracted position to the second, radially expanded position. The side groove can include a semicircular concave profile in the tool body. The side groove can be oriented substantially vertically and parallel to a longitudinal axis of the tool body. The side groove can be oriented substantially linearly along a length of the side groove between an uphole end and a downhole end of the side groove.

Some aspects of the disclosure encompass a method, including disposing a downhole well tool in a wellbore, where the downhole well tool includes a tool body attached to a well string, a sealing packer element partially circumscribing the tool body from a first circumferential end to a second circumferential end of the sealing packer element, and a fluid conduit disposed within the tool body. The method includes positioning a cable in a side groove formed at least partially in the tool body, the side groove positioned between the first circumferential end and the second circumferential end of the sealing packer element, the side groove configured to form a channel in an exterior surface of the tool body, and the cable configured to extend from a second well tool downhole of the tool body, through the channel of the side groove and across the sealing packer element, and toward a location uphole of the tool body. The method further includes flowing a fluid through the fluid conduit and through a nozzle at an end of the fluid conduit, the nozzle to direct the fluid flow into the side groove to surround a portion of the cable positioned in the side groove.

This, and other aspects, can include one or more of the following features. The method can include radially expanding the sealing packer element from a first, radially retracted position to a second, radially expanded position to engage and seal against a wall of the wellbore. The fluid can be a sealing resin, and flowing the fluid through the fluid conduit and through the nozzle can include flowing the sealing resin out of the nozzle and around the portion of the cable to fluidly seal the side groove. The method can further include pressure testing an annulus of the wellbore where the sealing resin is disposed around the portion of the cable. The downhole well tool can include an electric submersible pump packer, the cable can include an electric submersible pump cable, and the second well tool can include an electric submersible pump, and positioning the cable in the side groove can include extending the cable from the electric submersible pump, through the side groove of the electric submersible pump packer, and toward a surface location of the wellbore. The method can further include clamping the cable to the well string with a first clamp positioned downhole of the sealing packer element and with a second clamp positioned uphole of the sealing packer element.

In certain aspects, a downhole well system includes a first downhole tool, including a tool body attached to a well string, a sealing packer element partially circumscribing the tool body from a first circumferential end to a second circumferential end of the sealing packer element, the sealing packer element configured to expand and seal against an inner wall of a wellbore, and a side groove formed at least partially in the tool body and positioned between the first circumferential end and second circumferential end of the sealing packer element, where the side groove is configured to form a channel in an exterior surface of the tool body between the first circumferential end and the second circumferential end of the sealing packer element. The downhole well system also includes a second downhole tool configured to be disposed downhole of the first downhole tool, and a cable connected to the second downhole tool and extending toward the first downhole tool. The cable is positioned within the channel of the side groove between the first circumferential end and the second circumferential end of the sealing packer element, and the cable is configured to further extend to a location uphole of the tool body.

This, and other aspects, can include one or more of the following features. The first downhole tool can include a fluid conduit disposed within the tool body and extending to the side groove, where the fluid conduit includes at least one nozzle positioned at the side groove, and the fluid conduit configured to flow a fluid into the channel of the side groove.

The details of one or more implementations of the subject matter described in this disclosure are set forth in the accompanying drawings and the description below. Other features, aspects, and advantages of the subject matter will become apparent from the description, the drawings, and the claims.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is a schematic partial cross-sectional side view of an example well system including two example well tools.

FIG. 2 is a schematic partial cross-sectional front view of an example well tool disposed in a wellbore 202.

FIG. 3 is a schematic partial cross-sectional perspective view of the example well tool of FIG. 2 .

FIG. 4 is a schematic partial cross-sectional front view of an example well tool with a cable.

FIG. 5 is a schematic partial cross-sectional perspective view of the example well tool of FIG. 4 .

FIG. 6 is a flowchart describing an example method for sealing a wellbore with a downhole well tool.

Like reference numbers and designations in the various drawings indicate like elements.

DETAILED DESCRIPTION

This disclosure describes a downhole well tool that includes a sealing packer with a side groove that is substantially or completely vertically oriented on the side of the well tool and sealing packer. The side groove allows passage of a cable across the sealing packer without disrupting the perimeter seal between the sealing packer element and a wall of the wellbore, casing, or other tubing, and without squeezing the cable against the wall by the sealing packer. The side groove splits the circumference of the sealing packer element such that the sealing packer does not form a complete ring around the tool body of the downhole well tool. In some instances, the side groove is formed at least partially in the tool body of the downhole well tool that is radially inward of the sealing packer element, such that inner surfaces that form the side groove include a grooved portion of the tool body and circumferential end surfaces of the sealing packer element that are adjacent to the grooved portion of the tool body.

The cable can include a power cable, an electrical cable, a communications cable, a hydraulic cable, or another type of cable that extends from a location downhole of the sealing packer to another location uphole of the sealing packer. For example, the sealing packer can include a packer element for an electric submersible pump (ESP), and the cable can be an ESP cable that connects to an ESP unit that is positioned downhole of the sealing packer. The side groove is formed in the downhole well tool such that the side groove is present in instances where the sealing packer is substantially or fully expanded, for example, when the sealing packer is engaged with the wall of the wellbore, casing, or other tubular. The side groove is sized to completely or partially fit a continuous portion of the cable within the side groove along an entire longitudinal length of the side groove (for example, the length from a downhole end to an uphole end of the groove). The side groove can include a semicircular profile or a different shaped profile in the outer surface of the body of the downhole well tool that allows passage of the cable within the groove and longitudinally across the sealing packer element. The side groove allows for passage of the cable across the sealing element, even in instances where the sealing element is expanded to engage and seal against the inner wall of the wellbore, casing, or other tubing.

In some instances, a fluid conduit (or control line) extends within the body of the downhole well tool, and includes one or more nozzles (such as one-way nozzles) that are disposed within or on the side groove, and the nozzle(s) is fluidly connected to the side groove to deliver a fluid (for example, a sealing resin) to the space, or channel, defined by the side groove. The fluid is introduced to the side groove, flows around the cable portion that is disposed within the side groove to occupy the space within the side groove that surrounds the cable portion, and in some instances, partially or completely solidifies within the side groove to hold the cable in place within the side groove and to fluidly seal the side groove from fluid flow through the side groove and across the sealing packer. In certain instances, a well string that supports the downhole well tool and second downhole tool (for example, the ESP) includes one or more cable clamps to hold the cable in place relative to the well string, such as against or radially offset from the well string. For example, a first clamp holds the cable against an exterior surface of the well string at a location that is uphole of the sealing packer, and a second cable clamp holds the cable against an exterior surface of the well string at a location that is downhole of the sealing packer.

Conventional sealing packers for ESPs include a packer penetrator that requires a manual splice of the ESP cable, which leaves the cable vulnerable to hydrocarbons, heat, voltage stress, and conductive fluids. From the ESP unit, a conventional ESP cable is spliced and fed through the ESP packer, and spliced at another location. These splices can be subject to human error, can be time consuming to perform, and are vulnerable to electrical shorts. In the downhole well tool of the present disclosure, the cable is not required to be spliced, and ensures continuity of the cable while maintaining the sealing functionality of the sealing packer. The cable is passed through the side groove at the sealing packer, and can extend all the way to a surface location in one continuous line while maintaining the functionality of the sealing packer.

FIG. 1 is a schematic partial cross-sectional side view of an example well system 100 that includes a substantially cylindrical wellbore 102 extending from a well head 104 at a surface 106 downward into the Earth into one or more subterranean zones of interest 108 (one shown). The example well system 100 includes a vertical well, with the wellbore 102 extending substantially vertically from the surface 106 to the subterranean zone 108. The concepts herein, however, are applicable to many other different configurations of wells, including horizontal, slanted, or otherwise deviated wells. A well string 110 is shown as having been lowered from the surface 106 into the wellbore 102. In certain instances, after some or all of the wellbore 102 is drilled, a portion of the wellbore 102 is lined with lengths of tubing, called casing 112. The wellbore 102 can be drilled in stages, and the casing 112 may be installed between stages. The casing 112 can include a series of jointed lengths of tubing coupled together end-to-end or a continuous (for example, not jointed) coiled tubing. The casing 112 forms the cased section of the wellbore 102. In some examples, the well system 100 excludes casings, such as casing 112, and the wellbore 102 is at least partially or entirely open bore. The section(s) of the wellbore 102 exposed to the adjacent formation (for example, without casing or other permanent completion) form the open hole section 114 of the wellbore 102.

In the example well system 100 of FIG. 1 , the well string 110 connects to and supports a first downhole well tool 116 and a second downhole well tool 118 that is further downhole than the first downhole well tool 116. The first downhole well tool 116 and the second downhole well tool 118 can interact with fluids or other components within the wellbore 102, and can take the form of packer tools, pumps, drill bits, testing tools, production tools, or other well tools. In some instances, the first downhole well tool 116 is a sealing packer tool with a packer element that selectively seals against an inner wall of the wellbore 102 or casing 112, and the second downhole well tool 118 is an ESP. A cable 120 extends from the second downhole well tool 118 to the first downhole well tool 116 and further to the well head 104 at the surface 106 of the well. The cable 120 can include a power cable, a communications cable, an electrical cable, a hydraulic cable, a combination of these cables, or a different type of cable that is disposed in the annulus of the wellbore 102 and extends partially or entirely to the well head 104 or other surface location. The cable 120 is positioned along a groove (not shown) in a radially exterior surface of the first downhole well tool 116. The example sealing packer tool can seal against a wall of the wellbore 102, the example ESP can pump fluid uphole through the well string, and the cable 120 can provide power, control, communication, or a combination of these features to or from the surface of the well, from which the cable 120 extends.

The well string 110 can take a variety of different forms, for example, based on the type of tools that encompass the first downhole well tool 116 and the second downhole well tool 118. In some implementations, the well string 110 is a production string, a testing string, a drill string, a wireline, a completion string, or another type of tubing string. Though the example well system 100 of FIG. 1 shows two downhole well tools (116 and 118), the number of downhole well tools can vary. For example, the well system 100 can include additional well tools uphole of, downhole of, or between the first downhole well tool 116 and second downhole well tool 118. The well tools 116 and 118 are rugged enough to withstand the harsh wellbore environment and to be included on an active well string 110.

FIG. 2 is a schematic front view of an example well tool 200 disposed in a wellbore 202, and FIG. 3 is a schematic partial cross-sectional side view of the example well tool 200 disposed in the wellbore 202. The example well tool 200 can be used in the example well system 100 of FIG. 1 , such as the first downhole well tool 116 within wellbore 102 of FIG. 1 . The example well tool 200 includes a tool body 204, a sealing packer element 206 that partially circumscribes the tool body 204, and a side groove 208 formed partially in an exterior surface of the tool body 204. The tool body 204 attaches to and is carried on a well string 210 disposed in the wellbore 202. The tool body 204 is rigid, substantially cylindrical, and is positioned about a central longitudinal axis A-A. The tool body 204 has a first, uphole longitudinal end 214 and a second, downhole longitudinal end 216, and connects to tubing of the well string 210 on the first longitudinal end 214, the second longitudinal end 216, or both. In some examples, the tool body 204 includes threading or other connection structures to engage and connect to tubing or other well tools at the first longitudinal end 214, second longitudinal end 216, or both.

The sealing packer element 206 is radially expandable to engage and seal against an inner wall of the wellbore 202. The inner wall can be the inner surface of an open bore portion of the wellbore 202, an inner surface of a casing, or an inner surface of another tubing. The sealing packer element 206 can expand from a first, radially retracted position (as depicted in FIGS. 2 and 3 ) to a second, radially expanded position (as depicted in FIGS. 4 and 5 , described later). In the first position of the sealing packer element 206, the example well tool 200 can be run into and moved freely in the longitudinal direction within the wellbore 202. In the second position of the sealing packer element 206, the sealing packer element 206 is radially expanded to engage and fluidly seal against the inner wall of the wellbore 202, for example, to effectively plug (substantially or completely) the wellbore 202 from fluid flow across the sealing packer element 206.

In the example well tool 200 of FIGS. 2 and 3 , a circumference of the sealing packer element 206 is split at a location proximate to the side groove 208, such that the sealing packer element 206 partially circumscribes the tool body 204 from a first circumferential end 218, around the tool body 204, and to a second circumferential end 220 of the sealing packer element 206. In some examples, the sealing packer element 206 has a partial ring shape with a split, where the first circumferential end 218 and the second circumferential end 220 define the edges of the split. The split in the circumference of the sealing packer element 206 exposes the side groove 208 in the tool body 204 to an open space of the wellbore 202. In other words, the side groove 208 is positioned between the first circumferential end 218 and the second circumferential end 220 of the sealing packer element 206, and forms a channel in an exterior surface of the grooved tool body 204 and in the space between the first circumferential end 218 and second circumferential end 220 of the sealing packer element 206.

The example well tool 200 includes a fluid conduit 222 that is disposed within the tool body 204 and extends to the side groove 208, for example, to deliver and selectively flow a fluid into the side groove 208. The fluid conduit 222 can include a machined fluid pathway within the tool body 204, an embedded tubing in the tool body 204, or another type of fluid pathway capable of directing and flowing a fluid from a fluid source to the side groove 208. The fluid conduit 222 includes at least one nozzle 224 (two shown) in an exterior surface of the tool body 204 that defines the side groove 208. The nozzles 224 are flush with the exterior surface of the tool body 204, or set radially inward from the exterior surface of the tool body 204, so that the nozzles 224 do not extend beyond the exterior surface and into the space defined by the side groove 208. The nozzles 224 control the flow direction of the fluid into the side groove from the fluid conduit 222. In some examples, the nozzles 224 include passive one-way check valves, active control nozzles, or another type of nozzle that can selectively flow a fluid out of the fluid conduit 222 and into the side groove 208.

The example well tool 200 depicts two nozzles 224 oriented vertically along the side groove 208; however, the number, position, and orientation of the nozzle(s) 224 can vary. For example, the fluid conduit 222 can include only one nozzle, two nozzles, or three or more nozzles, and each of the nozzles 224 can be fluidly connected to the same fluid conduit 222 (for example, to deliver the same fluid to the side groove 208) or to multiple, respective, discrete fluid conduits (for example, to deliver two or more types of fluids to the side groove 208). In some examples, the nozzles 224 can be centered in the side groove 208 and vertically oriented in a linear pattern along a vertical longitudinal length of the side groove 208 in an even distribution. In certain implementations, the nozzles 224 can be distributed along the surface of the side groove 208 in an irregular pattern that includes nozzles that are centered, left-side oriented, right-side oriented, a combination of these, or otherwise distributed in the side groove 208. The orientation and distribution of the nozzles 224 can be chosen based on a desired flow pattern of fluid from the nozzles 224 into the side groove 208.

The fluid conduit 222 fluidly connects to a fluid source located at the well tool 200, proximate to the well tool 200, or at a remote location away from the well tool 200 and connected by an extension of the fluid conduit 222 or control line. In the example well tool 200 of FIGS. 2 and 3 , the fluid conduit 222 connects to a fluid source (not shown) positioned at a top surface of the wellbore 202 with a dedicated extension of the fluid conduit 222 that extends from the tool body 204 uphole into the annulus of the wellbore 202 and to the fluid source at the top surface of the wellbore 202. The extension of the fluid conduit 222 that resides in the annulus of the wellbore 202 is rugged enough to withstand the caustic fluids and harsh environment of the wellbore 202. In some instances, the extension of the fluid conduit 222 resides within the well string 210, such that it is protected from the wellbore 202 environment as the fluid conduit 222 extension extends between the tool body 204 and the fluid source. In certain instances, the fluid source is disposed within or on the example well tool 200, within the well string 210 (uphole or downhole of the tool body 204), or in another location that is proximate to the example well tool 200. In some instances, a pump connects to the fluid conduit 222 to pump the fluid through the fluid conduit 222 and out of the nozzles 224. In some examples, the pump is located at the well surface, though this location can vary.

The side groove 208 is sized and shaped to receive a cable (described later) that resides in the side groove 208 and extends between a first location downhole of the well tool 200 to a second location uphole of the well tool 200. The example well tool 200 of FIG. 2 shows the groove as substantially or exactly linear, oriented substantially or exactly vertically, and having a longitudinal length between an uphole end and downhole end of the side groove that is substantially longer (for example, at least four times longer) than a width of the side groove along a circumference of the tool body 204. For example, the side groove 208 is oriented substantially vertically and parallel to the longitudinal axis A-A of the tool body 204, and the side groove 208 is substantially linear along its length between an uphole end and a downhole end of the side groove 208. However, the size, shape, and orientation of the side groove 208 can vary. In some instances, the side groove is oriented at an angle away from the vertical, includes a curved shape along its length, or a combination of these, for example, to accommodate a coiled cable or an otherwise curved cable residing in the side groove 208. In certain instances, the side groove 208 can be wider or narrower, for example, to better accommodate a different sized cable in the side groove.

FIGS. 2 and 3 show the example well tool 200 without a cable, and show the sealing packer element 206 in the first, radially retracted position. FIGS. 4 and 5 are a schematic front view and a schematic partial cross-sectional side view, respectively, of the example well tool 200 with the sealing packer element 206 in the second, radially expanded position, and including a cable 400 that resides in the side groove 208 and extends across the sealing packer element 206. The cable 400 is positioned within the channel of the side groove 208 and extends in an uphole direction from a second well tool (not shown) that is positioned downhole of the tool body 204 of the example well tool 200, through the channel of the side groove 208 and across the sealing packer element 206, and toward a location uphole of the tool body 204. The cable 400 can include a power cable, a communications cable, a hydraulic cable, an electrical cable, a combination of these, or another type of cable that extends from a location downhole of the sealing packer element 206 to another location uphole of the sealing packer element 206. The cable 400 resides primarily in the annulus of the wellbore 202 between the second well tool downhole of the tool body 204 and another location uphole of the tool body 204, such as the well head of the wellbore 202. In some examples, the well tool 200 is a packer tool for an ESP, the cable 400 is an ESP power cable that connects to an ESP unit that is positioned downhole of the sealing packer element 206, and the cable 400 extends from the ESP unit, across the sealing packer element 206 of the packer tool, and to a surface of the wellbore 202 for connection to a power source.

In some implementations, the sealing packer element 206 includes an inflatable packer that inflates from the first position to the second position, a swellable packer that swells from the first position to the second position, a hydraulic actuated packer that actuates from the first position to the second position, or another type of expandable packer element.

The side groove 208 is formed in the example well tool 200 such that the side groove 208 is present in instances where the sealing packer element 206 is substantially or fully expanded, for example, when the sealing packer element 206 is engaged with the wall of the wellbore 202, casing, or other tubular. FIGS. 4 and 5 depict the sealing packer element 206 in the second, expanded position where the sealing packer element 206 is sealingly engaged with the wall of the wellbore 202. The side groove 208 is sized to completely or substantially fit a continuous portion of the cable 400 within the side groove 208 along an entire longitudinal length of the side groove 208 (for example, the length from the downhole end to the uphole end of the groove 208), to allow passage of the cable 400 across the example well tool 200 without disrupting the normal sealing operation of the sealing packer element 206 of the example well tool 200. The side groove 208 includes a semicircular concave profile in the outer surface of the tool body 204 of the example well tool 200 to substantially match the shape of the cable 400, and allows passage of the cable 400 within the side groove 208 and longitudinally across the sealing packer element 206 between its circumferential ends 218 and 220. The profile of the side groove 208 can vary, for example, to match a different shape of a cable that can reside in the side groove 208. For example, the side groove 208 can include a triangular profile, a squared profile, a deeper or shallower curved shape relative to a semicircular profile, or another profile shape. The side groove 208 allows for passage of the cable 400 across the sealing packer element 206, even in instances where the sealing packer element 206 is expanded to engage and seal against the inner wall of the wellbore 202, casing, or other tubing.

As shown in the example well tool 200 of FIGS. 2-5 , the side groove 208 forms the circumferential break in the sealing packer element 206. During operation of the example well tool 200, the sealing packer element 206 expands from the first, radially retracted position (as in FIGS. 2 and 3 ) to the second, radially expanded position (as in FIGS. 4 and 5 ) to substantially or completely engage and seal against the inner wall of the wellbore 202. In order to complete the fluid seal in the wellbore 202 by the sealing packer element 206 when the sealing packer element 206 is in the second, expanded position against the wall of the wellbore 202, the side groove 208 receives a sealing resin 402 or other sealing fluid from the fluid conduit 222 through the nozzles 224. As depicted in the example well tool 200 of FIGS. 4 and 5 , the sealing resin 402 flows into, fills, and plugs the channel defined by the side groove 208 between the circumferential ends 218 and 220 of the sealing packer element 206. The sealing resin 402 from the nozzles 224 flows around and envelops the portion of the cable 400 that resides in the side groove 208 in order to fluidly seal the side groove 208 with the cable 400 disposed within the channel of the side groove 208. For example, as the sealing resin 402 hardens, solidifies, or otherwise sets in the side groove 208, the sealing resin 402 completes the fluid seal and pressure seal in the wellbore 202 across the sealing packer element 206.

In certain instances, a volume of the side groove 208 is known, and a volume of the portion of the cable 400 within the side groove 208 is known, so the fluid conduit 222 delivers a known displacement volume of the sealing resin 402 to the side groove 208, for example, to ensure there is a sufficient quantity of the sealing resin 402 introduced to the side groove 208 to sufficiently envelop the portion of the cable 400 and seal the side groove 208. The sealing resin 402 can have a density substantially equivalent to (or greater than) the weight of existing fluid in the wellbore 202, such that the sealing resin 402 that is pumped or otherwise introduced to the side groove 208 will displace the existing fluid and stay suspended in the side groove 208 to seal around the cable 400. In some implementations, the annulus of the wellbore 202 can be pressure tested from the top surface of the wellbore 202 to determine the effectiveness of the seal provided by the sealing packer element 206 and sealing resin 402 in the side groove 208.

In some instances, the distance between a radially outer surface of the tool body 204 (not including the sealing packer element 206) and the wellbore wall is less than the diameter of the cable 400. The side groove 208 allows the cable 400 to reside adjacent to the tool body 204 so that the example well tool 200 can be run downhole with the cable 400 positioned in the side groove 208 with sufficient distance tolerance between the wellbore wall and the cable 400. In certain implementations, the side groove 208 may be defined by the split in the sealing packer element 206 without an inset groove (or other surface alteration) in the outer surface of the tool body 204 adjacent to the circumferential break in the sealing packer element 206. For example, in instances where the cable 400 has a diameter that is less than a distance between the radially outer surface of the tool body 204 (not including the sealing packer element 206) and the wellbore wall, the side groove 208 can be defined by the circumferential ends 218 and 220 of the sealing packer element 206 and the portion of the unaltered, cylindrical exterior surface of the tool body 204 that is between the circumferential ends 218 and 220 of the sealing packer element 206.

In some implementations, as depicted in FIGS. 4 and 5 , cable clamps 404 (two shown) hold and secure the cable 400 in place on the well string 210. For example, a first of the clamps 404 can hold the cable 400 against, or radially offset from, an exterior surface of the well string 210 at a location that is uphole of the sealing packer element 206, and a second of the clamps 404 can hold the cable 400 against, or radially offset from, the exterior surface of the well string 210 at a second location that is downhole of the sealing packer element 206. The example well tool 200 of FIGS. 4 and 5 show two clamps 404 on the well string 210, one clamp positioned just uphole of the example well tool 200 and another clamp positioned just downhole of the example well tool 200. However, the number and location of these clamps 404 can vary. For example, the well string 210 can carry just one clamp 404, positioned either uphole or downhole of the example well tool 200, or the well string 210 can carry three or more clamps distributed along the well string 210 to secure the cable relative to the well string 210 as the cable extends toward a top surface of the wellbore 202.

FIG. 6 is a flowchart describing an example method 600 for sealing a wellbore, for example, performed by the example well tool 200 in the wellbore 202 of FIGS. 2 to 5 . At 602, a downhole well tool is disposed in a wellbore. The downhole well tool includes a tool body attached to a well string, a sealing packer element partially circumscribing the tool body from a first circumferential end to a second circumferential end of the sealing packer element, and a fluid conduit disposed within the tool body. At 604, a cable is positioned in a side groove formed at least partially in the tool body. The side groove is positioned between the first circumferential end and the second circumferential end of the sealing packer element, and the side groove forms a channel in an exterior surface of the tool body. The cable extends from a second well tool downhole of the tool body, through the channel of the side groove and across the sealing packer element, and toward a location uphole of the tool body. At 606, a fluid flows through the fluid conduit and through a nozzle at an end of the fluid conduit. The nozzle directs the fluid flow into the side groove to surround a portion of the cable positioned in the side groove. In some implementations, the sealing packer element is radially expanded from a first, radially retracted position to a second, radially expanded position to engage and seal against a wall of the wellbore. In certain implementations, the fluid is a sealing resin, and flowing the fluid through the fluid conduit and through the nozzle includes flowing the sealing resin out of the nozzle and around the portion of the cable to fluidly seal the side groove. In some examples, the annulus of the wellbore is pressure tested after the sealing resin is disposed around the portion of the cable. The downhole well tool can include an ESP packer, the cable can include an ESP power cable, and the second well tool can include an ESP. In certain examples, the cable is clamped to the well string with one or more clamps positioned uphole, downhole, or both uphole and downhole of the sealing packer element.

A number of implementations have been described. Nevertheless, it will be understood that various modifications may be made without departing from the spirit and scope of the disclosure. 

1. A downhole well tool, comprising: a tool body configured to attach to a well string; a sealing packer element partially circumscribing the tool body from a first circumferential end to a second circumferential end of the sealing packer element, the sealing packer element configured to expand and seal against an inner wall of a wellbore; a side groove formed at least partially in the tool body and positioned between the first circumferential end and the second circumferential end of the sealing packer element, the side groove configured to form a channel in an exterior surface of the tool body between the first circumferential end and the second circumferential end of the sealing packer element; and a fluid conduit disposed within the tool body and extending to the side groove, the fluid conduit comprising at least one nozzle positioned at the side groove, the fluid conduit configured to flow a fluid into the channel of the side groove.
 2. The downhole well tool of claim 1, further comprising a cable positioned within the channel of the side groove and configured to extend from a well tool downhole of the tool body, through the channel of the side groove and across the sealing packer element, and to a location uphole of the tool body.
 3. The downhole well tool of claim 2, wherein the sealing packer element is an electric submersible pump packer, the cable is an electric submersible pump cable, and the downhole well tool is configured to connect to an electric submersible pump positioned downhole of the sealing packer element.
 4. The downhole well tool of claim 2, wherein the cable comprises at least one of a power cable, a communications cable, or a hydraulic cable.
 5. The downhole well tool of claim 2, further comprising a clamp configured to secure the cable to the well string.
 6. The downhole well tool of claim 5, wherein the clamp is a first clamp positioned downhole of the sealing packer element and configured to secure the cable downhole of the sealing packer element, the downhole well tool further comprising a second clamp positioned uphole of the sealing packer element, the second clamp configured to secure the cable to the well string uphole of the sealing packer element.
 7. The downhole well tool of claim 1, wherein the at least one nozzle comprises a plurality of nozzles fluidly connected to the fluid conduit, and the plurality of nozzles are distributed along the side groove.
 8. The downhole well tool of claim 7, wherein the plurality of nozzles are distributed in a linear pattern along a longitudinal length of the side groove.
 9. The downhole well tool of claim 8, wherein the plurality of nozzles are evenly distributed in the linear pattern.
 10. The downhole well tool of claim 1, wherein the sealing packer element comprises a partial ring shape with a split, wherein the first circumferential end and the second circumferential end define the split.
 11. The downhole well tool of claim 1, wherein the sealing packer element is radially expandable and configured to radially expand from a first, radially retracted position to a second, radially expanded position of the sealing packer element.
 12. The downhole well tool of claim 11, wherein the sealing packer element comprises an inflatable packer configured to inflate from the first, radially retracted position to the second, radially expanded position.
 13. The downhole well tool of claim 11, wherein the sealing packer element comprises a swellable packer configured to swell from the first, radially retracted position to the second, radially expanded position.
 14. The downhole well tool of claim 1, wherein the side groove comprises a semicircular concave profile in the tool body.
 15. The downhole well tool of claim 1, wherein the side groove is oriented substantially vertically and parallel to a longitudinal axis of the tool body.
 16. The downhole well tool of claim 1, wherein the side groove is oriented substantially linearly along a length of the side groove between an uphole end and a downhole end of the side groove.
 17. A method, comprising: disposing a downhole well tool in a wellbore, the downhole well tool comprising a tool body attached to a well string, a sealing packer element partially circumscribing the tool body from a first circumferential end to a second circumferential end of the sealing packer element, and a fluid conduit disposed within the tool body; positioning a cable in a side groove formed at least partially in the tool body, the side groove positioned between the first circumferential end and the second circumferential end of the sealing packer element, the side groove configured to form a channel in an exterior surface of the tool body, and the cable configured to extend from a second well tool downhole of the tool body, through the channel of the side groove and across the sealing packer element, and toward a location uphole of the tool body; and flowing a fluid through the fluid conduit and through a nozzle at an end of the fluid conduit, the nozzle to direct the fluid flow into the side groove to surround a portion of the cable positioned in the side groove.
 18. The method of claim 17, comprising radially expanding the sealing packer element from a first, radially retracted position to a second, radially expanded position to engage and seal against a wall of the wellbore.
 19. The method of claim 17, wherein the fluid is a sealing resin, and flowing the fluid through the fluid conduit and through the nozzle comprises flowing the sealing resin out of the nozzle and around the portion of the cable to fluidly seal the side groove.
 20. The method of claim 19, further comprising pressure testing an annulus of the wellbore where the sealing resin is disposed around the portion of the cable.
 21. The method of claim 17, wherein the downhole well tool comprises an electric submersible pump packer, the cable comprises an electric submersible pump cable, and the second well tool comprises an electric submersible pump, and wherein positioning the cable in the side groove comprises extending the cable from the electric submersible pump, through the side groove of the electric submersible pump packer, and toward a surface location of the wellbore.
 22. The method of claim 17, further comprising clamping the cable to the well string with a first clamp positioned downhole of the sealing packer element and with a second clamp positioned uphole of the sealing packer element.
 23. A downhole well system, comprising: a first downhole tool, comprising: a tool body attached to a well string; a sealing packer element partially circumscribing the tool body from a first circumferential end to a second circumferential end of the sealing packer element, the sealing packer element configured to expand and seal against an inner wall of a wellbore; and a side groove formed at least partially in the tool body and positioned between the first circumferential end and second circumferential end of the sealing packer element, the side groove configured to form a channel in an exterior surface of the tool body between the first circumferential end and the second circumferential end of the sealing packer element; and a second downhole tool configured to be disposed downhole of the first downhole tool; and a cable connected to the second downhole tool and extending toward the first downhole tool, the cable being positioned within the channel of the side groove between the first circumferential end and the second circumferential end of the sealing packer element, the cable configured to further extend to a location uphole of the tool body.
 24. The downhole well system of claim 23, wherein the first downhole tool further comprises a fluid conduit disposed within the tool body and extending to the side groove, the fluid conduit comprising at least one nozzle positioned at the side groove, the fluid conduit configured to flow a fluid into the channel of the side groove. 